Electrical wet-mate connections

ABSTRACT

Electrical cables are attached to an outer surface of production tubing. The electrical cables are configured to be connected at a first end to a topside electrical power supply. Electrical contacts are attached to a second end of the electrical cables. The contacts are at a downhole end of the production tubing.

TECHNICAL FIELD

This disclosure relates to electrical wet-mate connections within awellbore environment.

BACKGROUND

In hydrocarbon production, wellbores are formed in geologic formationscontaining hydrocarbon reserves. In some instances, hydrocarbonreservoir pressure is sufficient to produce hydrocarbon fluids from thereservoir, through the wellbore, and to a topside facility forprocessing. In some instances, artificial lift systems are needed toincrease production rates. Such artificial lift systems can include anelectric submersible pump (ESP). Electric submersible pumps generallydraw electrical power from a topside facility. The electric submersiblepump then mechanically adds kinetic energy, typically through acentrifugal rotor, to increase a production rate from the reservoir.

SUMMARY

This disclosure describes technologies relating to electrical wet-mateconnections.

An example implementation of the subject matter described within thisdisclosure is a wellbore stinger with the following features. Electricalcables are attached to an outer surface of production tubing. Theelectrical cables are configured to be connected at a first end to atopside electrical power supply. Electrical contacts are attached to asecond end of the electrical cables. The contacts are at a downhole endof the production tubing.

Aspects of the example wellbore stinger, which can be combined with theexample wellbore stinger alone or in combination with other aspects,include the following. The electrical cables are sized to deliversufficient electrical power to drive an electric submersible pump atfull load.

Aspects of the example wellbore stinger, which can be combined with theexample wellbore stinger alone or in combination with other aspects,include the following. A downhole end of the production tubing isconfigured to be received by a polished bore receptacle installed withina wellbore.

Aspects of the example wellbore stinger, which can be combined with theexample wellbore stinger alone or in combination with other aspects,include the following. The downhole end of the production tubingincludes a clocking feature configured to align the electrical contactswith corresponding contacts within the polished bore receptacle.

An example implementation of the subject matter described within thisdisclosure is an example method with the following features. An electricsubmersible pump is received by a wellbore. The electric submersiblepump is secured within the wellbore by a packer. A polished borereceptacle is received by the electric submersible pump. The polishedbore receptacle includes electrical contacts within an inner surface ofthe polished bore receptacle. A stinger is received by the polished borereceptacle. The stinger includes production tubing and electrical cablesattached to an outer surface of the production tubing. The electricalcables are configured to be connected at a first end to a topsideelectrical power supply. Electrical contacts are attached to a secondend of the electrical cables. The contacts are at a downhole end of theproduction tubing.

Aspects of the example method, which can be combined with the examplemethod alone or in combination with other aspects, include thefollowing. Electrical power by is exchanged with the electricsubmersible pump by the electrical cables and contacts. Fluid isproduced by the electric submersible pump.

Aspects of the example method, which can be combined with the examplemethod alone or in combination with other aspects, include thefollowing. The stinger is released by the polished bore receptacle.

Aspects of the example method, which can be combined with the examplemethod alone or in combination with other aspects, include thefollowing. The stinger is released, by the wellbore. The polished borereceptacle and the electric submersible pump remain secured within thewellbore.

Aspects of the example method, which can be combined with the examplemethod alone or in combination with other aspects, include thefollowing. The stinger is a first stinger. The method further includesreceiving a second stinger by the polished bore receptacle afterreleasing the first stinger by the wellbore.

Aspects of the example method, which can be combined with the examplemethod alone or in combination with other aspects, include thefollowing. The stinger is serviced after the stinger is released fromthe wellbore.

Aspects of the example method, which can be combined with the examplemethod alone or in combination with other aspects, include thefollowing. The stinger is received by the polished bore receptacle afterthe stinger is released by the polished bore receptacle.

An example implementation of the subject matter described within thisdisclosure is an example wellbore system with the following features. Astinger includes production tubing and electrical cables attached to anouter surface of the production tubing. The electrical cables areconfigured to be connected at a first end to a topside electrical powersupply. Electrical contacts are attached to a second end of theelectrical cables. The contacts are at a downhole end of the productiontubing. A polished bore receptacle is configured to receive and retain adownhole end of the stinger. An electric submersible pump is downhole ofthe polished bore receptacle.

Aspects of the example well system, which can be combined with theexample well system alone or in combination with other aspects, includethe following. The electrical cables are sized to deliver sufficientelectrical power to drive an electric submersible pump at full load.

Aspects of the example well system, which can be combined with theexample well system alone or in combination with other aspects, includethe following. The polished bore receptacle is uphole of a packerassembly, the packer assembly securing the electric submersible pumpwithin the wellbore.

Aspects of the example well system, which can be combined with theexample well system alone or in combination with other aspects, includethe following. The polished bore receptacle is downhole of a tubinghanger supporting the stinger.

Aspects of the example well system, which can be combined with theexample well system alone or in combination with other aspects, includethe following. The downhole end of the production tubing includes aclocking feature configured to align with a corresponding feature of thepolished bore receptacle. The clocking features are configured to alignthe electrical contacts of the stinger with corresponding electricalcontacts of the polished bore receptacle.

Aspects of the example well system, which can be combined with theexample well system alone or in combination with other aspects, includethe following. The electrical cables are a first set of electricalcables. A second set of electrical cables extends between the electricalcontacts within the polished bore receptacle and the electricsubmersible pump.

Aspects of the example well system, which can be combined with theexample well system alone or in combination with other aspects, includethe following. Casing within the wellbore is seven inch casing orgreater.

Particular implementations of the subject matter described in thisdisclosure can be implemented so as to realize one or more of thefollowing advantages. Tubing and tubing hangers can be changed outwithout risk to the electrical penetrations on the electric submersiblepump. Such reduction in risk reduces the non-production time caused bywell work.

The details of one or more implementations of the subject matterdescribed in this disclosure are set forth in the accompanying drawingsand the description below. Other features, aspects, and advantages ofthe subject matter will become apparent from the description, thedrawings, and the claims.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a schematic diagram of an example well system.

FIGS. 2A-2B are schematic diagrams of a bottomhole assembly and wet-mateconnector used with the example well system.

FIG. 3 is a flowchart of an example method that can be used with aspectsof this disclosure.

Like reference numbers and designations in the various drawings indicatelike elements.

DETAILED DESCRIPTION

Electric submersible pumps are typically connected to power cables bypenetrators. Penetrator failure can occur during tubing hangerinstallation. Such a failure requires the un-setting of packers to fixor replace the penetrator. This results in pulling essentially allcomponents (tubing, hangers, electric submersible pump, packers, etc.)from the wellbore and reinstalling them. Such an operation is extensiveand results in delays and extended non-production time.

This disclosure relates to a downhole arrangement that decouples theelectrical penetrations of the electrical submersible pump from theinstallation of tubing and hangers. The electric submersible pump isinstalled and secured within the wellbore with a packer. A polished borereceptacle, with electrical contacts, attached to, and uphole of, theelectric submersible pump. The production tubing is arranged as astinger with electrical cables attached to the outside of the productiontubing and electrical contacts at a downhole end of the tubingcorresponding with the electrical contacts of the polished borereceptacle. In such an arrangement, changing out the production tubinghas little to no impact on the electric submersible pump penetrations.

FIG. 1 is a schematic diagram of an example well system 100. The wellsystem 100 includes a wellbore 102 formed in a geologic formation 104.Extending into the wellbore 102 is a production string 106, alsoreferred to as production tubing. The production string 106 directsfluids from the geologic formation to a topside facility 108. Thetopside facility 108 includes pumps, compressors, separators, and anyother facilities necessary to condition fluids produced from thegeologic formation 104. At a downhole end of the production string 106is an electric submersible pump 110. The electric submersible pump 110assists in flowing the produced fluid up the production string 106towards the topside facility 108. The electric submersible pump 110 isdownhole of a polished bore receptacle 112 and is secured within thewellbore 102 by a packer 114. The polished bore receptacle 112 allowsfor the production string 106 to be installed and removed withoutremoving the electric submersible pump 110. In some implementations, thepolished bore receptacle 112 is downhole of a tubing hanger 116supporting the production tubing 106. While illustrated as a verticalwellbore for simplicity, the wellbore 102 can be a deviated orhorizontal wellbore without departing from this disclosure. In someimplementations, the concepts described herein are applicable with wellcasing diameters of seven inches or greater; however, other casingdiameters can be used without departing from this disclosure.

FIGS. 2A-2B are schematic diagrams of a bottomhole assembly 200 andwet-mate connector 202 used with the example well system 100. Thebottomhole assembly 200 includes the packer 114, the electricsubmersible pump 110, and the downhole end of the production string 106,colloquially referred to as a stinger 204. The stinger 204 (productiontubing 106) includes electrical cables 206 a attached to an outersurface of the production tubing 106. The electrical cables 206 a can beattached to the production tubing in a variety of ways, for example, byclamps 207. The electrical cables 206 a are configured to be connectedat a first, uphole end to an electrical power supply at the topsidefacility 108 (FIG. 1 ). The electrical cables 206 a are sized to deliversufficient electrical power to drive the electric submersible pump 110at full load. At a downhole end of the production tubing 106 areelectrical contacts 210 a electrically coupled and attached to a second,downhole end of the electrical cables 206 a. In some implementations,the electrical contacts 210 a include a pin or brush style contactconfigured to contact a corresponding groove, protrusion, or otherlongitudinally oriented contact. In some implementations, the electricalcontacts 210 a include brush contacts. In some implementations, theelectrical contacts include annular contacts. In such an implementation,clocking the stinger may not be necessary. Regardless of the type ofcontacts used, the electrical contacts 210 a and 210 b are ruggedized towithstand a wellbore environment.

The polished bore receptacle 112 is configured to receive and retain adownhole end of the stinger 204. Similarly, the downhole end of theproduction tubing 106 is configured to be received by a polished borereceptacle 112 installed within the wellbore 102. That is, the polishedbore receptacle 112 and the stinger 204 define profiles configured tomate with one another. In some implementations, the downhole end of theproduction tubing 106 includes a clocking feature 208 configured toalign with a corresponding feature of the polished bore receptacle 112.In such implementations, the clocking is used to align the electricalcontacts 210 a with corresponding contacts 210 b within the polishedbore receptacle 112. Such a clocking feature can include a slot andgroove.

A second set of electrical cables 206 b extends between the electricalcontacts within the polished bore receptacle 112 and the electricsubmersible pump 110. The second set of electrical cables are sized todeliver sufficient electrical power to drive the electric submersiblepump 110 at full load.

FIG. 3 is a flowchart of an example method 300 that can be used withaspects of this disclosure. At 302, the electric submersible pump 110 isreceived by the wellbore 102. The electric submersible pump 110 issecured within the wellbore 102 by a packer 114. At 304, the polishedbore receptacle 112 is received by the electric submersible pump. Thepolished bore receptacle includes electrical contacts within an innersurface of the polished bore receptacle 112. In some implementations,the polished bore receptacle 112 is received by the electric submersiblepump 110 prior to the electric submersible pump 110 being received bythe wellbore 102. At 306, a stinger 204 is received by the polished borereceptacle 112. The stinger includes production tubing configured todirect production fluids from the electric submersible pump 110 towardsthe topside facility 108. Electrical cables 206 a are attached to anouter surface of the production tubing 106 and are configured to beconnected at a first end to an electrical power supply, for example, atthe topside facility 108. At the downhole end of the stinger 204,electrical contacts 210 a are attached to the second end of theelectrical cables 206 a.

During operation, electrical power is exchanged between the electricsubmersible pump and the electrical cables and contacts. Fluid, such ashydrocarbons, are produced by the electric submersible pump in responseto the electrical power exchange.

At some point during the life of the wellbore, the stinger is releasedby the polished bore receptacle. The stinger is then released by thewellbore. That is, the stinger 204 is removed from the wellbore 102 andthe polished bore receptacle 112. As such, the polished bore receptacle112 and the electric submersible pump 110 remain secured within thewellbore 102. Such an operation can occur due to routine maintenance, orto repair something within the well.

In some instances, the stinger 204 is serviced after the stinger 204 isreleased or removed from the wellbore 102. The stinger 204 is thenreinstalled after servicing. That is, the stinger 204 is received by thepolished bore receptacle 112 after releasing the stinger 204 by thepolished bore receptacle 112. In some instances, the stinger 204 cannotbe serviced, salvaged, or otherwise reused. In such instances, a secondstinger is installed in lieu of the first, original stinger 204. Thatis, the second stinger 204 is received by the polished bore receptacleafter the first stinger 204 is removed or released from the wellbore102. In some implementations, the first stinger 204 and the secondstinger are substantially identical.

While this disclosure contains many specific implementation details,these should not be construed as limitations on the scope of what may beclaimed, but rather as descriptions of features specific to particularimplementations. Certain features that are described in this disclosurein the context of separate implementations can also be implemented incombination in a single implementation. Conversely, various featuresthat are described in the context of a single implementation can also beimplemented in multiple implementations separately or in any suitablesubcombination. Moreover, although features may be described above asacting in certain combinations and even initially claimed as such, oneor more features from a claimed combination can in some cases be excisedfrom the combination, and the claimed combination may be directed to asubcombination or a variation of a subcombination.

Similarly, while operations are depicted in the drawings in a particularorder, this should not be understood as requiring that such operationsbe performed in the particular order shown or in sequential order, orthat all illustrated operations be performed, to achieve desirableresults. Moreover, the separation of various system components in theimplementations described above should not be understood as requiringsuch separation in all implementations, and it should be understood thatthe described components and systems can generally be integratedtogether in a single product or packaged into multiple products.

Thus, particular implementations of the subject matter have beendescribed. Other implementations are within the scope of the followingclaims. In some cases, the actions recited in the claims can beperformed in a different order and still achieve desirable results. Inaddition, the processes depicted in the accompanying figures do notnecessarily require the particular order shown, or sequential order, toachieve desirable results

What is claimed is:
 1. A wellbore stinger comprising: production tubing;electrical cables attached to an outer surface of the production tubing,the electrical cables configured to be connected at a first end to atopside electrical power supply; and electrical contacts attached to asecond end of the electrical cables, the contacts being at a downholeend of the production tubing.
 2. The wellbore stinger of claim 1,wherein the electrical cables are sized to deliver sufficient electricalpower to drive an electric submersible pump at full load.
 3. Thewellbore stinger of claim 1, wherein a downhole end of the productiontubing is configured to be received by a polished bore receptacleinstalled within a wellbore.
 4. The wellbore stinger of claim 3, whereinthe downhole end of the production tubing comprises a clocking featureconfigured to align the electrical contacts with corresponding contactswithin the polished bore receptacle.
 5. A method comprising: receivingan electric submersible pump by a wellbore, the electric submersiblepump being secured within the wellbore by a packer; receiving a polishedbore receptacle by the electric submersible pump, the polished borereceptacle comprising electrical contacts within an inner surface of thepolished bore receptacle; and receiving a stinger by the polished borereceptacle, the stinger comprising: production tubing; electrical cablesattached to an outer surface of the production tubing, the electricalcables configured to be connected at a first end to a topside electricalpower supply; and electrical contacts attached to a second end of theelectrical cables, the contacts being at a downhole end of theproduction tubing.
 6. The method of claim 5, further comprising:exchanging electrical power by the electric submersible pump by theelectrical cables and contacts; and producing fluid by the electricsubmersible pump.
 7. The method of claim 5, further comprising:releasing, by the polished bore receptacle, the stinger.
 8. The methodof claim 7, further comprising releasing, by the wellbore, the stinger,the polished bore receptacle, and the electric submersible pumpremaining secured within the wellbore.
 9. The method of claim 8, whereinthe stinger is a first stinger, the method further comprising: receivinga second stinger by the polished bore receptacle after releasing thefirst stinger by the wellbore.
 10. The method of claim 8, furthercomprising servicing the stinger after the stinger is released from thewellbore.
 11. The method of claim 10, further comprising: receiving thestinger by the polished bore receptacle after releasing the stinger bythe polished bore receptacle.
 12. A wellbore system comprising: astinger comprising: production tubing; electrical cables attached to anouter surface of the production tubing, the electrical cables configuredto be connected at a first end to a topside electrical power supply; andelectrical contacts attached to a second end of the electrical cables,the contacts being at a downhole end of the production tubing; apolished bore receptacle configured to receive and retain a downhole endof the stinger; and an electric submersible pump downhole of thepolished bore receptacle.
 13. The wellbore system of claim 12, whereinthe electrical cables are sized to deliver sufficient electrical powerto drive an electric submersible pump at full load.
 14. The wellboresystem of claim 12, wherein the polished bore receptacle is uphole of apacker assembly, the packer assembly securing the electric submersiblepump within the wellbore.
 15. The wellbore system of claim 12, whereinthe polished bore receptacle is downhole of a tubing hanger supportingthe stinger.
 16. The wellbore system of claim 12, wherein the downholeend of the production tubing comprises a clocking feature configured toalign with a corresponding feature of the polished bore receptacle, theclocking features configured to align the electrical contacts of thestinger with corresponding electrical contacts of the polished borereceptacle.
 17. The wellbore system of claim 12, wherein the electricalcables are a first set of electrical cables, further comprising a secondset of electrical cables extending between the electrical contactswithin the polished bore receptacle and the electric submersible pump.18. The wellbore system of claim 12, wherein casing within the wellboreis seven inch casing or greater.